Antero Resources Reports Second Quarter 2016 Financial Results

DENVER, Aug. 2, 2016 /PRNewswire/ -- Antero Resources Corporation(NYSE: AR) ("Antero" or the "Company") today released its second quarter 2016 financial results. The relevant condensed consolidated financial statements are included in Antero's Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, which has been filed with the Securities and Exchange Commission.

Highlights Include:

GAAP net loss of $596 million, or $(2.12) per share, compared to a GAAP net loss of $145 million, or $(0.52) per share in the prior year quarter due to non-cash losses on unsettled hedges of $977 million and $198 million, respectively, driven by increasing commodity prices during each quarter

Adjusted net income of $41 million, or $0.14 per share, representing a 136% increase compared to the prior year quarter

Adjusted EBITDAX of $332 million, a 24% increase compared to the prior year quarter

Net daily production averaged a record 1,762 MMcfe/d, a 19% increase over the prior year quarter and flat sequentially

Included record net daily liquids production of 75,041 Bbl/d, a 63% increase over the prior year quarter and a 10% increase sequentially

Realized natural gas price before hedging averaged $1.93 per Mcf, a $0.02 negative differential to Nymex, with 99% of production priced at favorable markets

Realized natural gas equivalent price including NGLs, oil and hedges averaged $3.95 per Mcfe, a 3% increase over the prior year quarter

For the three months ended June 30, 2016, the Company reported a GAAP net loss of $596 million, or $(2.12) per basic and diluted share, compared to a GAAP net loss of $145 million, or $(0.52) per basic and diluted share, in the second quarter of 2015. The GAAP net loss for the second quarter of 2016 included the following items:

Non-cash loss on unsettled hedges of $977 million due to increasing commodity prices during the quarter

Non-cash equity-based stock compensation expense of $26 million

Impairment of unproved properties of $20 million

Without the effect of these items, the Company's results for the second quarter of 2016 were as follows:

Adjusted net income of $41 million, or $0.14 per basic and diluted share, a 136% increase compared to the second quarter of 2015

Adjusted EBITDAX of $332 million, a 24% increase compared to the second quarter of 2015

Cash flow from operations before changes in working capital of $269 million, a 29% increase compared to the second quarter of 2015

For a description of adjusted net income, adjusted EBITDAX and cash flow from operations before changes in working capital and reconciliations to their nearest comparable GAAP measures, please read "Non-GAAP Financial Measures."

Antero's net daily production for the second quarter of 2016 averaged 1,762 MMcfe/d, including 75,041 Bbl/d of liquids (26% liquids). Second quarter 2016 production represents an organic production growth rate of 19% from the second quarter of 2015 and flat compared to the first quarter of 2016. During the second quarter, Antero shut in 7.3 Bcfe, representing 80 MMcfe/d of production for the quarter due to operational downtime in late June at the Sherwood Processing Plant in West Virginia. Antero currently has no production shut in. Second quarter 2016 C3+ natural gas liquids ("NGLs") and oil production averaged 52,424 Bbl/d and 5,244 Bbl/d, respectively, while ethane (C2) production averaged 17,373 Bbl/d. Total liquids production for the second quarter of 2016 represents an organic production growth rate of 63% and 10% from the second quarter of 2015 and first quarter of 2016, respectively.

Antero's average natural gas price before hedging decreased 12% from the prior year quarter to $1.93 per Mcf, a $0.02 per Mcf negative differential to Nymex, as Nymex natural gas prices decreased 26% from the prior year quarter. Approximately 99% of Antero's second quarter 2016 natural gas revenue was realized at currently favorable price indices, including Columbia Gas Transmission (TCO), Chicago, MichCon, Tennessee Gulf and Nymex. Antero's average realized natural gas price after hedging for the second quarter of 2016 was $4.31 per Mcf, a $2.36 premium to the Nymex average price for the period. This represents a 12% increase compared to the prior year quarter. During the quarter, Antero realized a cash settled natural gas hedge gain of $283 million, or $2.38 per Mcf.

The Company's average realized C3+ NGL price before hedging for the second quarter of 2016 was $17.08 per barrel, or 38% of the Nymex WTI oil price, which represents a 5% increase as compared to the prior year quarter. Average realized oil price was $35.08 per barrel, a 20% decrease as compared to the second quarter of 2015 due to a 21% decrease in the Nymex WTI oil price. Antero's average realized ethane price for the second quarter of 2016 was $8.36 per barrel, or $0.20 per gallon. Antero's average realized C3+ NGL price including hedges was $18.98 per barrel, or $0.45 per gallon, a 3% decrease as compared to the second quarter of 2015.

Antero's average natural gas-equivalent price including C2+ NGLs and oil, but excluding hedge settlements, decreased from the prior year quarter by 11% to $2.13 per Mcfe due to a 21% decline in Nymex WTI and a 26% decline in Nymex natural gas prices. The Company's average natural gas-equivalent price, including C2+ NGLs, oil and hedge settlements, increased by 3% to $3.95 per Mcfe for the second quarter of 2016 as compared to the second quarter of 2015. For the second quarter of 2016, Antero realized a hedge settlement gain of $293 million, or $1.82 per Mcfe.

Total operating revenue for the second quarter of 2016 was $(249) million as compared to $377 million for the second quarter of 2015. Operating revenue for the second quarter of 2016 included a $977 million non-cash loss on unsettled hedges, while the second quarter of 2015 included a $198 million non-cash loss on unsettled hedges. In both periods, the non-cash loss on unsettled hedges was driven by increasing natural gas prices during the period. Revenue excluding the unrealized hedge loss was $728 million, a 27% increase compared to the second quarter of 2015. Liquids production contributed 33% of total revenue before hedges in the second quarter of 2016, as compared to a 25% contribution for the prior year quarter. For a reconciliation of revenue excluding unrealized hedge (gains) losses to operating revenue, the most comparable GAAP measure, please read "Non-GAAP Financial Measures."

Marketing revenue for the second quarter of 2016 was $91 million. Antero's marketing revenue was primarily associated with the sale of third party gas purchased to utilize the Company's excess firm transportation capacity on the Tennessee Gas Pipeline. Marketing expense for the second quarter of 2016 was $126 million. The largest components of marketing expense were the costs related to excess capacity and the cost of purchasing third party gas. Combining the two, net marketing expense was $35 million or $0.22 per Mcfe for the second quarter of 2016. For the second half of 2016, due to a third party contractual commitment effective July, 1, 2016, Antero has released to a third party certain unutilized firm transportation capacity and the costs associated with the unutilized capacity. As a result of the reduction in marketing expense, Antero expects net marketing expense to decrease to a range of $0.10 to $0.15 per Mcfe for the second half of 2016.

Per unit cash production expense (lease operating, gathering, compression, processing, transportation, and production tax) for the second quarter of 2016 was $1.48 per Mcfe, a 2% increase compared to $1.45 per Mcfe in the prior year quarter. The per unit cash production expense for the quarter included $0.08 per Mcfe for lease operating costs, $1.29 per Mcfe for gathering, compression, processing and transportation costs and $0.11 per Mcfe for production and ad valorem taxes. Per unit general and administrative expense for the second quarter of 2016, excluding non-cash equity-based compensation expense, was $0.21 per Mcfe, a 9% decrease from the second quarter of 2015. The significant per unit decrease in general and administrative expenses was primarily driven by the increase in production. Per unit depreciation, depletion and amortization expense decreased 6% from the prior year quarter to $1.23 per Mcfe, primarily driven by lower development costs.

Adjusted EBITDAX of $332 million for the second quarter of 2016 represents a 24% increase compared to the prior year quarter. Adjusted EBITDAX margin for the quarter was $2.06 per Mcfe, representing a 4% increase from the prior year quarter. For the second quarter of 2016, cash flow from operations before changes in working capital was $269 million, a 29% increase from the prior year quarter.

For a description of adjusted EBITDAX, adjusted EBITDAX margin, and cash flow from operations before changes in working capital and reconciliations to their nearest comparable GAAP measures, please read "Non-GAAP Financial Measures."

Low pressure gathering volumes for the second quarter of 2016 averaged 1,353 MMcf/d, a 40% increase from the second quarter of 2015 and a 4% increase sequentially. High pressure gathering volumes for the second quarter of 2016 averaged 1,253 MMcf/d, a 5% increase from the second quarter of 2015 and a 3% increase sequentially. Compression volumes for the second quarter of 2016 averaged 658 MMcf/d, a 45% increase from the second quarter of 2015 and a 9% increase sequentially. The increase in gathering and compression volumes was due to production growth from Antero in Antero Midstream's area of dedication. Condensate gathering volumes averaged 1,983 Bbl/d during the quarter, a 34% decrease compared to the prior year quarter and a 33% decrease sequentially. The sequential decrease in condensate gathering volumes was driven by Antero shifting Ohio Utica Shale development from its Highly-Rich Gas/Condensate area to higher rate of return drilling in the Highly-Rich Gas area, as well as the shifting of Antero Resources' development program to the Marcellus Shale from the Utica Shale, due to firm transportation constraints to premium markets in the Utica Shale. Fresh water delivery volumes averaged 105,379 Bbl/d during the quarter, an 11% increase compared to the prior year quarter and an 8% increase sequentially. The increase in fresh water delivery volumes was driven by operational efficiencies leading to accelerated Marcellus completions and an increase in the average water used per foot in completions to 41 barrels, a 25% increase as compared to 2015 and an 11% increase compared to the first quarter of 2016.

For the three months ended June 30, 2016, the Partnership reported revenues of $137 million. Revenues increased 55% compared to the prior year quarter, primarily driven by the startup of produced water handling and high rate transfer services in the first quarter of 2016. Direct operating expenses for the three months ended June 30, 2016 were $43 million. Direct operating expenses increased 138% year over year, driven primarily by the inclusion of produced water handling and high rate water transfer services, as well as the expansion of Antero Midstream's gathering and compression and fresh water delivery assets to support the production growth of Antero Resources. General and administrative expenses were $7 million during the second quarter of 2016, an increase of 17% compared to the second quarter of 2015. Total cash and non-cash operating expenses were $84 million, including $24 million of depreciation, $7 million of equity-based compensation, and $3 million of accretion of contingent acquisition consideration.

The Board of Directors of Antero Resources Midstream Management LLC, the general partner of Antero Midstream, declared a cash distribution of $0.25 per unit ($1.00 per unit annualized) for the second quarter of 2016. The distribution represents a 32% increase compared to the prior year quarter and a 6% increase sequentially. The distribution is Antero Midstream's sixth consecutive quarterly distribution increase since its initial public offering in November 2014 and will be payable on August 24, 2016 to unitholders of record as of August 10, 2016.

Balance Sheet and Liquidity

As of June 30, 2016, Antero's consolidated total debt and consolidated net debt were $4.2 billion, of which $900 million were borrowings outstanding under the Company's and Antero Midstream's revolving credit facilities. Total lender commitments under these two facilities are currently $5.5 billion. Including $708 million in letters of credit outstanding, the company had $3.9 billion in available consolidated liquidity as of June 30, 2016. For a reconciliation of consolidated net debt to consolidated total debt, the most comparable GAAP measure, please read "Non-GAAP Financial Measures."

Second Quarter 2016 Capital Spending

Antero's drilling and completion costs for the three months ended June 30, 2016 were $315 million. In addition, the Company invested $30 million for land and $1 million in other capital projects. Antero Midstream invested $48 million for gathering and compression systems and $42 million for water infrastructure projects including $33 million on the Antero Clearwater treatment facility during the quarter.

Hedge Position

Antero currently has hedged 3.4 Tcfe of future natural gas equivalent production using fixed price swaps covering the period from July 1, 2016 through December 31, 2022 at an average index price of $3.71 per MMBtu.

The following table summarizes Antero's hedge positions held as of June 30, 2016:

Period

Natural Gas

MMBtu/d

Average

Index price

($/MMBtu)

Liquids

Bbl/d

Average

Index price

3Q 2016:

TCO

60,000

$4.81

—

—

Nymex HH

1,110,000

$3.44

—

—

Dom South

272,500

$5.24

—

—

CGTLA

170,000

$4.03

—

—

Propane MB ($/Gallon)

—

—

30,000

$0.58

3Q 2016 Total

1,612,500

$3.86

30,000

$0.58

4Q 2016:

TCO

60,000

$5.01

—

—

Nymex HH

1,110,000

$3.57

—

—

Dom South

272,500

$5.47

—

—

CGTLA

170,000

$4.20

—

—

Propane MB ($/Gallon)

—

—

30,000

$0.61

4Q 2016 Total

1,612,500

$4.01

30,000

$0.61

2017:

Nymex HH

1,370,000

$3.39

—

—

CGTLA

420,000

$4.27

—

—

Chicago

70,000

$4.57

—

—

Propane MB ($/Gallon)

—

—

31,500

$0.42

2017 Total

1,860,000

$3.63

31,500

$0.42

2018

2,002,500

$3.91

2,000

$0.65

2019

2,330,000

$3.70

—

—

2020

1,377,500

$3.66

—

—

2021

630,000

$3.36

—

—

2022

120,000

$3.24

—

—

Conference Call

A conference call is scheduled on Wednesday, August 3, 2016 at 9:00 am MT to discuss the results. A brief Q&A session for security analysts will immediately follow the discussion of the results for the quarter. To participate in the call, dial in at 888-347-8204 (U.S.), 855-669-9657 (Canada), or 412-902-4229 (International) and reference "Antero Resources". A telephone replay of the call will be available until Friday, August 12, 2016 at 9:00 am MT at 877-870-5176 (U.S.) or 858-384-5517 (International) using the passcode 10086424.

A simultaneous webcast of the call may be accessed over the internet at www.anteroresources.com. The webcast will be archived for replay on the Company's website until Friday, August 12, 2016 at 9:00 am MT.

Presentation

An updated presentation will be posted to the Company's website before the August 3, 2016 conference call. The presentation can be found at www.anteroresources.com on the homepage. Information on the Company's website does not constitute a portion of this press release.

Non-GAAP Financial Measures

Revenue excluding unrealized hedge (gains) losses as set forth in this release represents total operating revenue adjusted for unsettled hedge (gains) and losses. Antero believes that revenue excluding unrealized hedge (gains) losses is useful to investors in evaluating operational trends of the Company and its performance relative to other oil and gas producing companies. Revenue excluding unrealized hedge (gains) losses is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for total operating revenue as an indicator of financial performance. The following table reconciles total operating revenue to revenue excluding unrealized hedge (gains) losses (in thousands):

Three months ended

June 30,

Six months ended

June 30,

2015

2016

2015

2016

Total operating revenue

$

376,714

$

(249,198)

$

1,606,401

$

471,806

Hedge (gains) losses

2,227

684,634

(757,327)

404,710

Cash receipts for settled hedges

195,880

292,500

380,720

616,847

Revenue excluding unrealized hedge (gains) losses

$

574,821

$

727,936

$

1,229,794

$

1,493,363

Adjusted net income as set forth in this release represents net income (loss), adjusted for certain items. Antero believes that adjusted net income is useful to investors in evaluating operational trends of the Company and its performance relative to other oil and gas producing companies. Adjusted net income is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for net income (loss) as an indicator of financial performance. The following table reconciles net income (loss) to adjusted net income (in thousands):

Three months ended

Six months ended

June 30,

June 30,

2015

2016

2015

2016

Net income (loss)

$

(145,373)

$

(596,244)

$

249,058

$

(601,299)

Non-cash commodity derivative (gains) losses on unsettled derivatives

198,107

977,134

(376,607)

1,021,557

Impairment of unproved properties

26,339

19,944

34,916

35,470

Equity-based compensation

27,582

25,816

55,365

49,286

Contract termination and rig stacking

1,937

—

10,902

—

Income tax effect of reconciling items

(91,307)

(385,928)

114,324

(417,401)

Adjusted net income

$

17,285

$

40,722

$

87,958

$

87,613

Cash flow from operations before changes in working capital as presented in this release represents net cash provided by operating activities before changes in working capital. Cash flow from operations before changes in working capital is widely accepted by the investment community as a financial indicator of an oil and gas company's ability to generate cash to internally fund exploration and development activities and to service debt. Cash flow from operations before changes in working capital is also useful because it is widely used by professional research analysts in valuing, comparing, rating and providing investment recommendations of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Cash flow from operations before changes in working capital is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for cash flows from operating, investing, or financing activities, as an indicator of cash flows, or as a measure of liquidity.

The following table reconciles net cash provided by operating activities to cash flow from operations before changes in working capital as used in this release (in thousands):

Three months ended

June 30,

Six months ended

June 30,

2015

2016

2015

2016

Net cash provided by operating activities

$

243,668

$

238,538

$

595,108

$

578,706

Net change in working capital

(35,361)

30,218

(94,344)

(18,612)

Cash flow from operations before changes in working capital

$

208,307

$

268,756

$

500,764

$

560,094

The following table reconciles consolidated total debt to consolidated net debt as used in this release (in thousands):

December 31,

June 30,

2015

2016

Bank credit facilities

$

1,327,000

$

900,000

6.00% senior notes due 2020

525,000

525,000

5.375% senior notes due 2021

1,000,000

1,000,000

5.125% senior notes due 2022

1,100,000

1,100,000

5.625% senior notes due 2023

750,000

750,000

Net unamortized premium

6,513

5,974

Net unamortized debt issuance costs

(39,731)

(36,960)

Consolidated total debt

$

4,668,782

$

4,244,014

Cash and cash equivalents

23,473

28,251

Consolidated net debt

$

4,645,309

$

4,215,763

Adjusted EBITDAX is a non-GAAP financial measure that the Company defines as net income (loss) from continuing operations including noncontrolling interest after adjusting for those items shown in the table below. Adjusted EBITDAX, as used and defined by the Company, may not be comparable to similarly titled measures employed by other companies and is not a measure of performance calculated in accordance with GAAP. Adjusted EBITDAX should not be considered in isolation or as a substitute for operating income, net income, cash flows from operating, investing and financing activities, or other income or cash flow statement data prepared in accordance with GAAP. Adjusted EBITDAX provides no information regarding a company's capital structure, borrowings, interest costs, capital expenditures, and working capital movement or tax position. Adjusted EBITDAX does not represent funds available for discretionary use because those funds may be required for debt service, capital expenditures, working capital, income taxes, franchise taxes, exploration expenses, and other commitments and obligations. However, Antero's management team believes adjusted EBITDAX is useful to an investor in evaluating the Company's financial performance because this measure:

is widely used by investors in the oil and gas industry to measure a company's operating performance without regard to items excluded from the calculation of such term, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired, among other factors;

helps investors to more meaningfully evaluate and compare the results of Antero's operations from period to period by removing the effect of its capital structure from its operating structure; and

is used by the Company's management team for various purposes, including as a measure of operating performance, in presentations to its board of directors, as a basis for strategic planning and forecasting and by its lenders pursuant to covenants under its credit facility and the indentures governing the Company's senior notes.

There are significant limitations to using adjusted EBITDAX as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect Antero's net income, the lack of comparability of results of operations of different companies and the different methods of calculating adjusted EBITDAX reported by different companies. The following tables represent a reconciliation of the Company's net income (loss) from continuing operations including noncontrolling interest to adjusted EBITDAX, a reconciliation of adjusted EBITDAX to net cash provided by operating activities and a reconciliation of realized price before cash receipts for settled hedges to adjusted EBITDAX margin (in thousands except adjusted EBITDAX margin).

Three months ended

Six months ended

June 30,

June 30,

2015

2016

2015

2016

Net income (loss) from continuing operations including noncontrolling interest

$

(139,483)

$

(575,490)

$

259,688

$

(564,840)

Commodity derivative (gains) losses

2,227

684,634

(757,327)

404,710

Gains on settled derivative instruments

195,880

292,500

380,720

616,847

Interest expense

59,823

62,595

113,008

125,879

Income tax expense (benefit)

(84,089)

(376,494)

163,249

(371,679)

Depreciation, depletion, amortization, and accretion

177,454

197,982

360,154

390,162

Impairment of unproved properties

26,339

19,944

34,916

35,470

Exploration expense

628

1,109

1,999

2,123

Equity-based compensation expense

27,582

25,816

55,365

49,286

Equity in earnings of unconsolidated affiliate

—

(484)

—

(484)

State franchise taxes

(106)

—

129

39

Contract termination and rig stacking

1,937

—

10,902

—

Total Adjusted EBITDAX

268,192

332,112

622,803

687,513

Interest expense

(59,823)

(62,595)

(113,008)

(125,879)

Exploration expense

(628)

(1,109)

(1,999)

(2,123)

Changes in current assets and liabilities

35,361

(30,218)

94,344

18,612

State franchise taxes

106

—

(129)

(39)

Other non-cash items

460

348

(6,903)

622

Net cash provided by operating activities

$

243,668

$

238,538

$

595,108

$

578,706

Three months ended

Six months ended

June 30,

June 30,

Adjusted EBITDAX margin ($ per Mcfe):

2015

2016

2015

2016

Realized price before cash receipts for settled hedges

$

2.40

$

2.13

$

2.72

$

2.12

Gathering, compression, and water handling revenues

0.04

0.02

0.03

0.02

Lease operating expense

(0.05)

(0.08)

(0.05)

(0.07)

Gathering, compression, processing and transportation costs

(1.23)

(1.29)

(1.23)

(1.29)

Marketing, net

(0.22)

(0.22)

(0.17)

(0.23)

Production taxes

(0.17)

(0.11)

(0.17)

(0.11)

General and administrative(1)

(0.23)

(0.21)

(0.23)

(0.21)

Adjusted EBITDAX margin before settled hedges

0.54

0.24

0.90

0.23

Cash receipts for settled hedges

1.45

1.82

1.42

1.93

Adjusted EBITDAX margin ($ per Mcfe):

$

1.99

$

2.06

$

2.32

$

2.16

(1) Excludes equity-based stock compensation that is included in G&A

Antero Resources is an independent natural gas and oil company engaged in the acquisition, development and production of unconventional liquids-rich natural gas properties located in the Appalachian Basin in West Virginia, Ohio and Pennsylvania. The Company's website is located at www.anteroresources.com.

This release includes "forward-looking statements". Such forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond Antero's control. All statements, except for statements of historical fact, made in this release regarding activities, events or developments the Company expects, believes or anticipates will or may occur in the future, such as those regarding future production targets, completion of natural gas or natural gas liquids transportation projects, future earnings, future capital spending plans, improved and/or increasing capital efficiency, continued utilization of existing infrastructure, gas marketability, maximized realized natural gas and natural gas liquids prices, acreage quality, access to multiple gas markets, expected drilling and development plans, future financial position, future technical improvements and future marketing opportunities, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All forward-looking statements speak only as of the date of this release. Although Antero believes that the plans, intentions and expectations reflected in or suggested by the forward-looking statements are reasonable, there is no assurance that these plans, intentions or expectations will be achieved. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in such statements.

Antero cautions you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond the Company's control, incident to the exploration for and development, production, gathering and sale of natural gas, NGLs and oil. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating natural gas and oil reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described under the heading "Item 1A. Risk Factors" in Antero's Annual Report on Form 10-K for the year ended December 31, 2015.

ANTERO RESOURCES CORPORATION

Condensed Consolidated Balance Sheets

December 31, 2015 and June 30, 2016

(unaudited)

(In thousands, except per share amounts)

December 31, 2015

June 30, 2016

Assets

Current assets:

Cash and cash equivalents

$

23,473

28,251

Accounts receivable, net of allowance for doubtful accounts of $1,195 in 2015 and 2016